Well packer



JIR. BROWN Feb. 27, 1968 WELL PACKER 6 Sheets-5heet l Filed April l,1966 J. R. BROWN Feb. '27, 1968 WELL PACKER e sneetshet 2 Filed April l.1966 ATTORNEYS J. R. BROWN Feb. 27, 1968 WELL PACKER 6 SheetsJSheet 5Filed April 1, 1966 ArrQzP/vfys EEST J. R. BROWN Feb. 27, 1968 WELLPACKER 6 Sheets`Sheet 4 Filed April l, 1966 dof R. BROWN NVENTOR.

Arromfys J. R. BROWN Feb. 27, 1968 WELL PACKER Filed April l, 1966ATTORNEYS Feb. 27, 1968 Filed April 1, 1966 J. R. BROWN WELL PACKER 6Sheets`Sheet 6 0E TN@ 19% ATTORNEYS United States Patent O 3,370,651WELL PACKER Joe R. Brown, 849D Katy Road,

Houston, Tex. 77024 Filed Apr. 1, 1966, Ser. No. 539,387 9 Claims. (Cl.166-134) The present invention relates to new and useful improvements indual-production well packers and particularly to a hydraulically set,mechanically released dualproduction well packer.

The invention is applicable for use in anchoring Well device, such aswell packers and the like, or well tubing, within the Vbore of the well.

In certain dual-production well packers the forces exerted upon theassembly have been carried by only one of the tubular supports. Thisunequal distribution of tension forces to thetwo tubular supports causesa bowing of the well packer assembly. Such bowing results in a cookingof the sealing assembly. When the packing element of the sealingassembly is cocked or displaced out of axial alignment with the wellbore, the packing element fails to hold well pressures.

l This cocking of the packing element occurs in dualproduction wellpackers whenever one of the tubular supports is slidable in one of theabutments, usually to allow release of the well packer from setposition, and the other tubular support is secured to both abutments.The unequal distribution of tension forces may occur during setting ofthe well packer assembly or when the pressure loading held bytheassembly is not uniformly distributed to the two tubular supports.

. Dual-production well packers, which employ a single set of grippinglelements for locking the packer against longitudinal movement in bothdirections, have come into general use for producing well fluids fromtwo producing formations through independent tubing strings. Theparticular advantage of a packer having the single set of grippingelements locking in both directions is the elimina tion of radiallymovable hydraulically actuated holddown means. Although these packershave been satisfactory lunder lower Apressure conditions, it has lbeenfound that under higher pressure conditions the forces increase and tendto place an excessive tension on the single tubing string. Suchexcessive tension produces the unequal distribution of forces and causesthe aforementioned cooking problem. In some instances, the excessivetension may actually bend the tubing string, which is carrying the fullload, at a point below the packer assembly.

In mechanically releasa-ble well packers, the release mechanismgenerally heretofore relied on has included a threaded connectionbetween one of the tubular supports l and one of the abutments wherebywhen the tubular support is rotated, the abutment is moved a sufficientdistance to'allow the packing and anchoring assembly to be unset. Attimes lwhere the well packer has remained set for a long period of timein a wel] bore, actuation of such threaded connections has provendifficult, and in some cases, impossible. I

It is, therefore, an important object of the present invention toprovide a new and improved well packer assembly having two tubularsupports extending through an upper'and a lower abutment and, when set,are both held by both of said abutments to at least partially equalizethe forces between said tubular supports and thereby eliminate theaforesaid diiculty of cocking of the packing element.

Another object of the present invention is to provide a new and improvedhydraulically set, mechanically released dual-production well packerincluding an alternate method of releasing the well packer from its setposition within a well bore.

rice

A further object is to provide an improved hydraulically set,mechanically released dual-production well packer which, when set, holdsagainst longitudinal movements of the well packer in both directions andutilizes forces developed in the tubular supports of the well packer toincrease the setting force holding against longitudinal movement.

Still another object is to provide an improved dual- .production wellpacker having two tubular supports including means to distribute forcesto the two tubular supports when said well packer is set and todisengage from said tubular supports for release.

A still further object is to provide an impr-oved dualproduction wellpacker having two tubular supports ano upper and lower abutmentsengaging said tubular supports when said well packer is set and one ofsaid abutments disengaging from said tubular supports for release ofsaid well packer.

The construction designed to carry out the invention will -behereinafter described, together with other features thereof.

The invention will be more readily understood from a reading of thefollowing specification by reference to the accompanying drawingsforming a part thereof, wherein an example of the invention is shown,and wherein:

FIGURE l is a longitudinal sectional view of a dualproduction wellpacker embodying the princi-ples of the present invention showing thewell packer in position within the well bore ready for setting;

FIGURE 2 is a similar View showing the well packer with its packingassembly moved to set position;

FIGURE 3 is another similar view of the Well packer illustrating thepacking assembly set and the anchoring assembly partially set;

FIGURE 4 is another similar View of the well packer showing the completeset position;

FIGURE 5 is another longitudinal sectional View of the well packerillustrating the initial release of the force distributing means priorto release of the packing and anchoring assemblies;

FIGURE 6 is another longitudinal sectional view illustrating thecomplete release of the well packer;

FIGURE 7 is a partial longitudinal sectional View of the well packertaken along line 7-7 in FIGURE l;

FIGURE 8 is a transverse sectional view through the anchoring assemblyof the well packer taken along line 8 8 in FIGURE l;

FIGURE 9 is a transverse sectional view of the force distributing meansof the well packer taken along line 9-9 in FIGURE l;

FIGURE lO is a longitudinal sectional view of the well packer in setposition and including the alternate releasing means having cut the rsttubular support for release of the well packer;

FIGURE 1l is another longitudinal sectional View of the well packer incomplete released position, which release has been accomplished by thealternate release method; and

FIGURE l2 is a perspective exploded View showing the relationship of theinsert to the lower abutment.

Referring more in detail to the drawings, the well packer as illustratedis designed to be run into lthe well bore defined by the casing Csupported on a first tubing string T-1. When the well packer hasbeenlowered to the level at which it is to be set, the second tubing stringT-2 is lowered into the well bore and landed in the well packer. Thewell packer, illustrated in FIGURE l, is positioned Within the casing Cat the level for setting with the second tubing string T-Z landed. Theother components of the well packer are shown in their running position.

The well packer is provided with a packing assembly P and an anchoringassembly A mounted on the rst and 3 second tubular supports, or mandrelsand 12, at a position between the upper abutment 14 and the lowerabutment 16. The packing assembly P is of the usual type which willexpand radially outward into sealing engagement with the interior of thecasing C when it is subjected to longitudinal compression. The anchoringassembly A is provided with suitable gripping elements which areexpanded outwardly into gripping engagement with the interior of thecasing C to hold the well packer assembly against longitudinal movementin both directions. The setting means S is also mounted surrounding thetubular supports 10 and 12 and is responsive to uid pressure, normally ahydraulic Huid, to move the packing assembly P and the anchoringassembly A into set position. The force distributing means F is mountedsurrounding the tubular supports 10 and 12 immediately below the settingmeans S and is adapted to provide engagement between the lower ends ofthe tubular supports 1t! and 12 to at least partially equalize thetension forces in such tubular supports. The release means R surroundsthe lower end of the tubular support 12 and retains the lower abutment16 in iixed position until such release means is actuated.

'Ihe rst tubular support 10 is connected to the rst tubing string T-l,extends through the upper abutment 14 and is free to rotate thereinmoving a limited longitudinal distance with respect thereto. The upperabutment 14 is provided with a bore through which the first tubularsupport 18 extends and a counterbore 18 in which the snap ring 20, whichengages in a groove in the exterior of tubular support 10, is positionedto allow a limited longitudinal movement of the tubular support 10 withrespect to the upper abutment 14. To prevent the Isnap ring from moving`out of the lower end of the counterbore 18, the nut 22 is threaded intothe counter- -bore 18. The bearing rings 24 are provided between theupper end of the nut 22 and the snap ring 20 to facilitate the rotationof the tubular support 10 and the snap ring 20 within the upper abutment14.

The tubular support 12 is threadedly secured into the lower portion ofthe upper abutment 14 opposite the tubular support 10 and is incommunication with the bore 26 into which the second tubing string T-2is landed. The pins 28 are adapted to be received in the J-slots 30 ofthe second tubing string T-2 when it is landed in the bore 26 of theupper abutment 14. The second tubing string T-2 is provided withsuitable packing to seal against the interior of the bore 26 when it ispositioned therein.

The packing assembly P which provides a seal against the well boresurrounds the two tubular supports 10 and 12 immediately below the upperabutment and includes the two resilient sealing elements 32 and 34 andthe central sealing follower 36.V To seal the packing assembly along theexterior immediately surrounding the two tubular supports 10 and 12, thesealing follower is provided with the O-rings 38 and 40 which sealbetween the interior of the follower and the exterior surfaces,respectively, of the tubular supports 10 and 12.

To hold the well packer when set against longitudinal movement, theanchoring assembly A is positioned immediately below the packingassembly P and includes an upper lexpander 42, the cage 44, the lowerexpander 46 and the gripping elements 48 which have outwardly projectingteeth adapted to, when moved radially outward, engage the interiorsurface of the casing C in pipe-gripping position. The upper expander 42abuts the lower surface' of the sealing element 34. The anchoringassembly A is setby a longitudinal movement of the expanders 42 and 46with respect to the gripping slips 48 whereby the tapered surfaces ofthe expanders wedge the slips radially -outward into gripping engagementwith the casing C. The cage 44 is releasably secured to the upperexpander 42 by the shear pin 50 and also releasably secured to the lowerexpander 46 by the shear pin 52. Relative rotation of the expanders withrespect to the cage 44 and the gripping Islips, 48 is prevented by thepin 54, which Vis secured to the upper expander 42 and extends outwardlyto the longitudinal slot 56 in the cage 44, and the pin 58, which issecured in the lower expander 46 and extends outwardly into thelongitudinal slot 60 Vin the cage 44. The anchoring assembly A, when inunset position, is supported on the tubular support 12 by the snap ring62. which is p0- sitioned in a groove in the exterior of the Ytubularsupport 12 and engages the lower side of the upper expander 42surrounding the tubular support 12.

The relative movement for setting both the packing assembly P and theanchoring assembly A is accomplished lby the exposure of the settingmeans S to hydraulic ui'd pressure, hereinafter more fully explained.The setting means S surrounds the tubular supports 10 and 12 `andincludes the ring 64 abutting the lower abutment 16 and threadedlysecured to the cylinder 66 whichsurrounds the tubular supports 10 and12'and the lower projection of the lower expander 46. Thus, thecylindef66 provides a chamber in which the lower part of lower 'expander46 is contained, and by the inclusion of suitable sealing means, thelower expander 46, when exposed Vto pressure, is urged in an upwarddirection to accomplish setting of the well packer. The cylinder 66is'r'eleasably secured to the lower expander 46 by the shear pin 68. Theshear pins 50, S2 and 68 will, therefore, retain the well packer inunset or running position as it is moved downwardly into the casing" C.vA pressure chamber ,70 is formed within the cylinder 66 andsurroundingtubular supports 1G and 12 between the lower edgefof thelower expander 46 and the upper surface of the ring 64.Communication isestablished into this pressure chamber 70 -through the tubular support12 by the ports 72.,Wher 1 actuated xby pressure, the setting means S isadapted. to cause the lower expander 46 to move upward within thecylinder 66. l l

In order lto prevent having to maintain pressure ,in the chamber 70 tohold the well packer in set position,` a locking means 74 is providedwhich is best illustrated in FIGURE 7. The locking means includes thetwo pins 76 and 78 which are threadedly secured intothleilow'er portionof the lower expander 46 and extend downwardly through the ring 64 inthe lower .abutment 16."' I`l'ie locking ring 64 is recessed to receivethe annular pistons 80 and 82 surrounding the pins 76 and 78,respectively, and also the insert bushings 84 and 86, which extendthrough the lower abutment 16, and arethreaded into the lower end of thering 64. The locking slips 88 and 90 are, positioned within the taperedinterior recess of the insert'bushings 84 and 86 and are engaged attheir upperfsurface by the annular pistons and '82, respectively.Eachlof the locking slips has upwardly directed teeth to allow the pins76 and 78 to readily move upward within the slips `and to preventdownward movementof the pins 76 and,78 with respect to the ring 64. Thelower exteriors ofthe pins 76 and 78 are providedvwith the snap rings92and 9.4, respectively. Y Y

The force distributing means F includes thereleasable engaging means orthreaded insert 96 which is adapted to engage the threads on theexterior ofthe second tubular support 12. Insert 96 is provided witha-projectionry 98 which is adapted to engage the exterior of the tubularsupport 10. As best seen in FIGURE 1, this insert 96 is held in threadedengagement with the threaded portion of tubular support 12 by theengagement of the exterior of the tubular Support 10 with the projection98; As seen in FIGURE 1, the first tubular -supportf 10 in normalposition is provided with a reduced external diameter or recess 100 onits exterior surface immediately below the point of engagement with theprojection 98-on the insert 96. This recess '100 continues downwardon'the exterior of the tubular support 10 and terminates inthe releasingmeans R or threaded releasable connecting means 102 between the exteriorof the tubular support 10 and the sleeve 104. The threads of releasemeans R connect the sleeve 104 to the tubular support 10. Sleeve 104 issecured to lower abutment 16. Thus, the release means R retains thelower abutment 16 in its fixed position with reference to the upperabutment 14, so long as the release connection R is not actuated Toeffect a build up of suitable pressure within pressure chamber 70 of thesetting means, the lower portion of the tubular support 12 is providedwith the seat 106 which is adapted to receive a ball or other suitableplug 108 when it is desired to move the well packer assembly to setposition.

As stated, the well packer assembly, when lowered to the level withinthe well bore as defined by the casing C at which it is desired to beset, is supported by the tubing string T-l; and, thereafter, the tubingstring T-2 is landed within the bore 26 in upper abutment 14 with thepin 28 engaged in the J-slot 30 of the second tubing string T-Z. Duringrunning of the well packer, setting is prevented by the shear pins 50,52 and 68 which are more than suficiently strong to support the weightof the well packer on the tubing string T-1 as it is lowered into thewell bore.

With the well packer assembly positioned at the desired level within thecasing C, the ball 108 is dropped through the second tubing string lT-2,and, when it lands on the seat 106, closes the lower end of the secondtubular support -12 allowing a fluid pressure build-up in the secondtubing string T-2. The Huid pressure is then conducted through the ports72 into the pressure chamber 70. The pressure is exerted downward on thering 64, which is held against movement by the lower abutment 16supported by the sleeve 104 and the releasable connecting means 102, andalso is exerted upward on the lower expander 46.

The three shear pins 50, 52 and 68 are of varying strength to controlthe sequence of setting. Shear pin 68 is the weakest of the three shearpins and, therefore,

' shears first. Shear pin 52 is the strongest of the three shear pinsand is the last to shear, as hereinafter more fully explained.

The initial setting action responsive to the pressure 'developed in thepressure chamber 70 initially shears the `shear pin 68. The pressure,thereafter, moves the anchoring assembly upwardly as a unit to set thepacking assembly P. This upward movement longitudinally compresses thesealing elements 32 and 34 between the upper abutment 14 and the upperexpander 42. Being resilient, the sealing elements 32 and 34 moveradially outward into sealing engagement with the interior of the casingC. When the packing assembly P has been completely set, it offerssuicient resistance to the continued upward movement of the anchoringassembly A to prevent further upward movement of upper expander 42. Thisposition is illustrated in FIGURE 2. Thereafter, the shear pin 50, beingof intermediate strength with respect 'to the three shear pins, issheared, and the cage 44 and lower expander 4.6 are moved upward withrespect to the upper expander 42. This moves the gripping elements 48upward on the inclined surfaces of the upper expander 42 to cause thegripping elements 48 to move outward into engagement -with the interiorof the casing C. This position is illustrated in FIGURE 3. When thegripping elements 48 are in tight engagement with the casing C, theyresist further upward movement. Thereafter, the pressure developedwithin the pressure chamber 70 forces the lower expander'46 in an upwarddirection and shears the shear pin 52. The continued application ofpressure forces the .lower expander 46 upward under the grippingelements 48 to wedge vthem firmly into pipe-gripping engagement with theinterior of the casing C. This position is illustrated in FIGURE 4. i

Duringthe setting operation, the lower expander 46 is moved upward withrespect to the lower abutment 16. As it moves upward, its threadedengagement with the pins 76 and 78 draws the pins upward through theinsert bushings 84 and 86, the locking slips 88 and 90 and the pistonsand 82. The pressure in the chamber 70 is exerted downward on thepistons 80 and 82 to urge the locking slips 88 and 90 into firmengagement with the inner tapered surface of the insert bushings 84 and86, and, further, this taper forces the locking slips 88 and 90 intogripping engagement with the pins 76 and 78, respectively, to preventany return movement of the lower expander 46. In this manner, the Wellpacker assembly, when completely set, is retained in the set positionuntil positively released, as hereinafter more fully explained. Theinterior of the lower expander 46 immediately surrounding the secondtubing support 12 is spaced outward therefrom to allow it to movereadily upward over the snap ring 62 `without interferring with thesetting of the well packer.

In this completely set position, the insert 96 is held in engagementwith the second tubular support 12 by tubular support 10 engaging theprojection 98. Being confined between the ring 64 and the lower abutment16, insert 96 functions to transmit forces between the tubular supportsand to exert such force to maintain the set position of the well packer.For example, a downward force on the tubular support 12 is exertedthrough its threaded connection to the insert 96. This force istransmitted by the insert 96 to the lower abutment 16 and through thesleeve 104 and the releasable connecting means 102 to the tubularsupport 10. Such force acts through the tubular support 10 to urge theupper abutment downwardly to further urge sealing engagement of thepacking assembly A and urging the upper expander 42 into tighterengagement with the gripping members 48. This assures' that the wellpacker assembly remains in set position. An upward force on the secondtubular support 12 immediately adjacent the point of engagement with thepiece 96 is exerted through the piece 96 to the ring 64 and through thelocking means 74, including the locking slips 88 and and the pins 76 and78, to the lower expander 46 to ure lower expander 46 upwardly intofirmer engagement with the gripping members 48.

When it is desired to remove the well packer assembly from the wellbore, normally the second tubing string T-2 is removed. Release isaccomplished by the rotation of the tubing string T-1 which rotates thefirst tubular support 10 with respect to the sleeve 104 in the lowerabutment 16. Initially, this liftsV the first tubing string T-l toposition the recess 100 opposite or in registry with the projection 98on the insert 96. When the tubing string T-l has been lifted thisdistance, the insert 96 moves out of engagement with the second tubularsupport 12 and is positioned as shown in FIGURE 5. Continued rotation ofthe first tubing string T-1 completes release of the releasing means R.Thereafter, complete release of the well packer is accomplished bylifting of the first tubing string T-1. This causes engagement betweenthe snap ring 20 with the upper end of the counterbore 18 lifting theupper abutment 14. The packing assembly P moves to its normal relaxedposition as upper abutment 14 is lifted above the upper expander 42.Continued lifting vof the upper abutment 14 raises the tubular supports10 and 12. When the snap ring 62 engages the lower surface of the upperexpander 42, the lifting moves the upper expander upward out from underthe gripping members 48. When the upper expander 42 has been completelyretracted, the pin 54 engages the upper end of the slot 56 in the cage44 lifting the cage and, thereby moving the cage and gripping slips 48upward to allow a complete retraction of the gripping slips 48 out ofgripping engagement with the casing C. If desired, the teeth on thelower part of the gripping slips 48 may be of reduced height to assistin release of the anchoring assembly as suggested in the Cicero C. Brownpatent application Ser. No. 299,982, filed Aug. 5, 1963. With the wellpacker assembly completely released, it may be retrieved from the wellbore.

Since on completion of the unthreading of the releasable connectingmeans 102 the lower abutment 16 and .sleeve 104 are not connected toeither tubular support,

they are supported by the bushings 84 and 86 which can vmove downward onthe pins 76 and 78 only until they come into engagement with and aresupported by the snap rings 92 and 94.

When the alternate method of releasing and retrieving the wellpackerassembly is incorporated into the device, the tubular support 16 isconnected by the collar 110, to the rst tubing string T-1, as shown bestin `FIG- URE 10. The collar 110 includes a recess 112 around itsinterior portion providing a shoulder 114 facing downward to receive theexible clips 116 on a wire line cutting tool 118. With this onguration,the wire line tool 118 may be lowered through the rst tubing string T-l,and, when it is determined that it is approximately the desiredposition, lifted Auntil the clips 116 engage the shoulder 114.Thereafter, cutting operation proceeds as illustrated in FIGURE '10. Theengagement of the clips 116 against the shoulder 114 positions thecutting of the tubular support 10 ata position immediately above thethreaded connection 102 and in the area of reduced externalvdiarneter100.

This reduced diameter portion 1000i the tubular support 10 provides aminimum thickness of wall through which to cut and also allows a spacebeyond the exterior of the tubular support to prevent damageto any ofthe remainder of the well packer by the cutting. This alternate methodcontemplates theuse of any wir-e line tubing cutter which will cutthrough the reduced portion of tubular support 10 without cutting theremainder of the well packer. A standard wire line tubing cutter may beused since the wall of the tubular support 10 in the reduced portion 100is normally no thicker than a standard tubing wall. l

To accomplish this alternate method of release with the wireline cuttingtool 118 positioned as hereinbefore described, the tubular support 1t)is cut immediately above the threaded connection 102 through the reduceddiameter portion 100. Release is then accomplished by lifting of thefirst tubing string T-1 upwardly so that the snap ring 20 engages theupper end of the counterbore 18 to lift the upper abutment 14 and allowthe packing assembly P to return to relaxed position. This also allowsthe insert 96 to release from tubular support 12. Thereafter, continuedlifting of the upper abutment 14 lifts the tubular support 12 to causethesnap ring 62 to engage the underside of the upper expander 42retracting the expander 42 from under the gripping elements 48. Furtherlifting positions the pin 54 in the upper end of the vertical slot 56 inthe cage to lift lthe cage 44 upward and to move the gripping members 48upward off the lower expander 46 thereby retracting the gripping membersfrom gripping engagement with the casing C. This completes `theunsetting of the anchoring assembly A and the well packer assembly maybe retrieved by lifting the tubing string T-l. t .-fNormally, it will bea general practice to remove the wireline cutting tool 118 beforeunsetting of the well packer assembly. This is possible by retaining theweight on the tubing string T-I while the wire line cutting tool isvlifted. The clips 116 are designedr to have sucient weakness so thatwhen it is desired to remove the cutting tool 118, lifting of the wireline shears the clips 116 and the cutting tool may be retrieved lfromthe tubingstring T-`1. When it is ycompletely removed, the release ofthe -the first tubular support onrelease allowsrelease ofthe insert fromthe second tubular support. Also, ythis reduced diameter portionprovides a position for the cutting lof the first Atubular support toprovide for thepositive release of the well packer in the event thenormal release means becomes inoperative. I

The foregoing disclosure and description of the invention areillustrative and explanatory thereof, and various changes in the size,shape and materials, as wellasin the details of the illustratedconstruction, may ,befmade within the scope of the appended claimswithout departing from the spirit of the invention. t

What is claimed is:

1. A dual-production well packer adapted toy be lowered and set within awell bore, comprising a iirst tubular'support,

a second tubular support, 1 t

an upper abutmentsurrounding said tubular supports and secured to saidsecond tubular support,

means connecting said first tubular support to said upper abutmentwhereby said iirst tubular support maybe rotated within said upperabutment and to provide-a limited longitudinal movement of said firsttubular support with respect to said upper abutment,

a lower abutment surrounding saidy tubular supports and spacedlongitudinally thereon below said upper abutment,

an anchoring assembly, including gripping elements,

mounted on said tubul-ar supports between said abutments,

setting means mounted on said tubular supports van coacting with saidanchoring assembly to move said assembly into set position whenactuated, 1

the settingV of said anchoring assembly moving said gripping elements ofsaid anchoring assembly into pipe-gripping position with said well boreto vhold against longitudinal movement in both directions,l

means releasa'bly connecting said first tubular support to said lowerabutment, and

'means c-oacting with said lower abutment and releasably engaging saidsecond tubular support to' hold vsaid second tubular support against'longitudinal movement with respect to said lower abutment,

said releasable engaging means coacting with said lower abutment andsaid releasable connecting means to' at least partially equalize tensionforces in saidl frstand second tubular supports. 'v l 2. Adual-production wellpacker according to claim '1,

wherein said first tubular support maintains said engaging means inengagement with said second tubular support.

3. A dual-production well packer according to claim`2, wherein Y M j ffrelease of said releasable 'connecting means providing a limitedl'longitudinal movement of said first tubular support with respect tosaid upper abutment and said lower abutment,` e such'longitudinalmovement-of said rst tubular support releasing said engaging means fromsaid second v tubular support whereby said upper abutment is'l free tovbe liftedwith said tubular supports vto relea'seth'e well packer fromset position. u 4. A dual-production well packer according to claimt',wherein said engaging means includes Y y an insert adapted to releasablyengage said second ytubular support and wherein t a portion of said.first tubular support coacts withaid insert to maintain said insert invengagement with said second tubular support,

, said first tubular support includes a reduced external diameterportion positioned adjacent said portion of said first tubular supportmaintaining said insert in engagement with said second'tubular support,

limited longitudinal movement of said first tubularfsupport moving saidreduced diameter portion of said first tubular support opposite saidinsert and providing space for said insert to move out of engagementwith said second tubular support. 5. A dual-production well packeraccording to claim 1, including a packing assembly mounted on saidtubular supports between said abutments and adapted to be moved intosealing engagement with the well bore by said setting means. 6. Adual-production well packer according to claim 1, including means insaid second tubular support to engage said anchoring assembly andrelease said gripping elements from pipe-gripping position after releaseof said engaging means and responsive to lifting of said second tubularsupport. 7. A dual-production Well packer according to claim 1, whereinsaid connecting means between said first tubular support and said upperabutment provides for rotation of said first tubular support within saidupper abutment, and rotation of said first tubular support releases saidconnecting means between said first tubular support and said lowerabutment. 8. A dual-production well packer according to claim 1, whereinthe external diameter of said first tubular support is reducedimmediately above said releasable connecting means and is therebyadaptable for cutting to release said anchoring assembly from setposition.

9. A dual-production well packer according to claim 8,

including a collar connecting said rst tubular support to a first tubingstring, and

an internal recess in said collar positioned to locate a cutter withinsaid first tubular support to cut through the reduced diameter portionof said rst tubular support above said releasable connecting meanswhereby lifting of the upper end of said first tu'bular support releasesaid engaging means and releases -said anchoring assembly frompipe-gripping position.

References Cited UNITED STATES PATENTS 3,145,777 8/1964 Cochran 166-1893,166,127 1/1965 Brown et al 166-189 3,191,682 6/1965 Cochran 166-1893,335,800 8/1967 Myers 166-189 JAMES A. LEPPINK, Primary Examiner.

1. A DUAL-PRODUCTION WELL PACKER ADAPTED TO BE LOWERED AND SET WITHIN AWELL BORE, COMPRISING A FIRST TUBULAR SUPPORT, A SECOND TUBULAR SUPPORT,AN UPPER ABUTMENT SURROUNDING SAID TUBULAR SUPPORTS AND SECURED TO SAIDSECOND TUBULAR SUPPORT, MEANS CONNECTING SAID FIRST TUBULAR SUPPORT TOSAID UPPER ABUTMENT WHEREBY SAID FIRST TUBULAR SUPPORT MAY BE ROTATEDWITHIN SAID UPPER ABUTMENT AND TO PROVIDE A LIMITED LONGITUDINALMOVEMENT OF SAID FIRST TUBULAR SUPPORT WITH RESPECT TO SAID UPPERABUTMENT, A LOWER ABUTMENT SURROUNDING SAID TUBULAR SUPPORTS AND SPACEDLONGITUDINALLY THEREON BELOW SAID UPPER ABUTMENT, AN ANCHORING ASSEMBLY,INCLUDING GRIPPING ELEMENTS, MOUNTED ON SAID TUBULAR SUPPORTS BETWEENSAID ABUTMENTS, SETTING MEANS MOUNTED ON SAID TUBULAR SUPPORTS ANDCOACTING WITH SAID ANCHORING ASSEMBLY TO MOVE SAID ASSEMBLY INTO SETPOSITION WHEN ACTUATED,